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CALGARY, ALBERTA--(Marketwired - Feb. 13, 2014) -
(Canadian Dollars Except as Indicated)
This news release contains "forward-looking information and statements" within the meaning of applicable securities laws. For a full disclosure of the forward-looking information and statements and the risks to which they are subject, see the "Cautionary Statement Regarding Forward-Looking Information and Statements" later in this news release.
The Board of Directors of Precision Drilling Corporation PD PDS ("Precision" or the "Corporation") has declared a first quarter dividend on Precision's common shares of $0.06 per share, payable on March 14, 2014, to shareholders of record on February 27, 2014. For Canadian income tax purposes, all dividends paid by Precision on its common shares are designated as "eligible dividends", unless otherwise indicated by the Corporation.
Net earnings this quarter were $68 million, or $0.24 per diluted share, compared to a net loss of $116 million, or $0.42 per diluted share, in the fourth quarter of 2012. In the fourth quarter of 2012, we recognized charges associated with asset decommissioning and a goodwill impairment that, combined, reduced net earnings by $179 million and net earnings per diluted share by $0.63.
Revenue this quarter was $567 million, or 6% higher than the fourth quarter of 2012, mainly because of higher international and U.S. drilling activity and higher pricing in Canadian contract drilling partially offset by lower turnkey activity in the United States.
Earnings before income taxes, finance charges, foreign exchange, impairment of goodwill, loss on asset decommissioning and depreciation and amortization ("adjusted EBITDA") this quarter were $198 million or 12% higher than the fourth quarter of 2012. Our adjusted EBITDA margin was 35% this quarter, compared to 33% in the fourth quarter of 2012. The increase in adjusted EBITDA margin was mainly due to increases in international and U.S. contract drilling activity and lower costs in U.S. contract drilling. Our activity for the quarter, as measured by drilling rig utilization days, increased 3% in the United States and 43% internationally, and decreased 1% in Canada compared to the fourth quarter of 2012.
For the year ended December 31, 2013, net earnings were $191 million or $0.66 per diluted share compared to net earnings of $52 million or $0.18 per diluted share in 2012. Revenue for the year was $2,030 million compared to $2,041 million in 2012. Adjusted EBITDA totaled $639 million for 2013 compared to $671 million in 2012, a decrease of 5%. Improved pricing in Canada and increased activity internationally were offset by lower activity levels in both the Contract Drilling and Completion and Production Services segments. Activity for Precision in 2013, as measured by drilling rig utilization days, decreased 6% in Canada and 13% in the United States compared to 2012, while international activity increased 70%.
Kevin Neveu, Precision's President and Chief Executive Officer, stated: "Precision's fourth quarter financial performance was a result of strengthening demand for our Tier 1 rigs, continued improvement in dayrates and excellent cost control by our drilling groups. Precision's High Performance, High Value strategy and our position as a preeminent driller for North America's unconventional resources is beginning to deliver the financial returns we expect."
"In the United States our activity bottomed in the second quarter at 77 rigs and today we are operating 95 rigs and our fourth quarter results reflect strengthening dayrates and margins. Our customers clearly recognize the efficiency and performance of Precision's Tier 1 rig fleet and we are pleased to see this value realized in our results."
"In our Canadian operations, Precision's focused investments are providing strong returns from new build and upgraded rigs for deeper unconventional drilling and pad drilling for heavy oil. These opportunities provide higher long-term returns compared to managing our business to meet short-term utilization targets. Fourth quarter activity was slightly lower than 2012, but Precision's increasing share of the Tier 1 market is driving dayrates, which continue to trend upwards with nearly a $1,000 per day increase year over year."
"The fourth quarter was the first time our international drilling division delivered results from as many as 12 rigs active, with modest startup expense drag, contributing to our results at a more normal run rate. We are optimistic about this division's performance in 2014 with the two ST-3000 rig deployments in Kuwait later this year. Additionally, the recent integrated project management awards could lead to several more rigs in Mexico for Precision."
"While our Completion and Production Services group continues to be challenged by low customer demand, I am pleased with our move into the northern U.S. during 2013. This geographic expansion leveraged our core completion and production capabilities, diversified our footprint, and continues to provide the opportunity to create value for a larger customer base."
"While 2013 may be seen as disappointing in some respects, as customer demand and activity waned for the first half of the year, the momentum that began to build in our third quarter and gained real traction for Precision in the fourth quarter, sets up a strong start to 2014. The consistently firm oil prices and the weather-driven improved natural gas prices should prove to be positive short-term catalysts. Furthermore, crude transportation debottlenecking and the potential for natural gas exports are encouraging long-term catalysts for Precision."
"With today's dividend announcement, Precision will have declared $89 million in dividend payments to shareholders in the past 14 months," concluded Mr. Neveu.
SELECT FINANCIAL AND OPERATING INFORMATION
Financial Highlights
----------------------------------------------------------------------------
(Stated in thousands
of Canadian Three months
dollars, except ended Year ended
where noted) December 31, December 31,
% %
2013 2012 Change 2013 2012 Change
----------------------------------------------------------------------------
Revenue 566,909 533,948 6.2 2,029,977 2,040,741 (0.5)
Adjusted EBITDA(1) 197,744 177,026 11.7 638,833 670,792 (4.8)
Adjusted EBITDA % of
revenue 34.9% 33.2% 31.5% 32.9%
Net earnings (loss) 67,921 (116,339) n/m 191,150 52,360 265.1
Cash provided by
operations 94,452 136,317 (30.7) 428,086 635,286 (32.6)
Funds provided by
operations(1) 155,816 142,576 9.3 461,973 598,812 (22.9)
Capital spending:
Expansion 53,734 123,063 (56.3) 282,145 596,194 (52.7)
Upgrade 29,926 22,706 31.8 141,132 130,094 8.5
Maintenance and
infrastructure 39,382 40,881 (3.7) 112,527 141,769 (20.6)
Proceeds on sale (3,351) (17,603) (81.0) (13,372) (31,423) (57.4)
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Net capital spending 119,691 169,047 (29.2) 522,432 836,634 (37.6)
Net earnings (loss)
- per share ($):
Basic 0.24 (0.42) n/m 0.69 0.19 263.2
Diluted 0.24 (0.42) n/m 0.66 0.18 266.7
Dividend paid per
share ($) 0.06 0.05 20.0 0.21 0.05 320.0
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(1) Adjusted EBITDA and funds provided by operations are additional GAAP
measures. See "ADDITIONAL GAAP MEASURES".
n/m - calculation not meaningful
Operating Highlights
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Three months ended Year ended
December 31, December 31,
% %
2013 2012 Change 2013 2012 Change
----------------------------------------------------------------------------
Contract drilling rig
fleet 327 321 1.9 327 321 1.9
Drilling rig utilization
days:
Canada 8,201 8,242 (0.5) 30,530 32,352 (5.6)
United States 8,258 8,014 3.0 30,268 34,597 (12.5)
International 1,052 736 42.9 3,555 2,086 70.4
Service rig fleet 222 214 3.7 222 214 3.7
Service rig operating
hours 71,981 77,234 (6.8) 283,576 294,681 (3.8)
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Financial Position
----------------------------------------------------------------------------
(Stated in thousands of Canadian dollars, December 31, December 31,
except ratio) 2013 2012
----------------------------------------------------------------------------
Working capital 305,783 278,021
Long-term debt(1) 1,323,268 1,218,796
Total long-term financial liabilities 1,355,535 1,245,290
Total assets 4,579,123 4,300,263
Long-term debt to long-term debt plus equity
ratio(1) 0.36 0.36
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(1) Net of unamortized debt issue costs.
Revenue in the fourth quarter of this year was $33 million higher than in 2012 mainly because of higher international and U.S. drilling activity and higher pricing in Canadian contract drilling partially offset by lower turnkey activity in the United States. In addition, activity levels in our Completion and Production Services segment were higher in the United States and lower in Canada. Compared to the fourth quarter of 2012, revenue from our Contract Drilling Services segment increased 7% while revenue in our Completion and Production Services segment remained consistent.
Adjusted EBITDA margin (adjusted EBITDA as a percentage of revenue) was 35% this quarter, compared to 33% in the fourth quarter of 2012. The increase in adjusted EBIDTA margin was mainly due to improved profitability in international and U.S. contract drilling operations, and new build and upgraded rigs that we have deployed over the past few years offset by weaker demand for our completion and production services. Our portfolio of term customer contracts, a highly variable operating cost structure and economies achieved through vertical integration of our supply chain all support the sustainability of our adjusted EBITDA margins.
Our vision is to be recognized as the High Performance, High Value provider of services for global energy exploration and development. We work toward that vision by defining and measuring our results against strategic priorities. Our 2014 priorities are to:
1. Continue to execute our High Performance, High Value strategy. Invest in
Precision's physical and human capital infrastructure to advance field
level professional development, provide industry leading service to
customers and demand safe operations. Continue to measure and benchmark
performance with a view to exceed the high standards we set.
2. Leverage our scale in operations. Utilize established systems to promote
consistent and reliable service and to reduce operating costs across all
geographies and service lines.
3. Seize the growth opportunities in front of us. Deliver new build and
upgraded rigs to customer contracts, expand international activity in
existing theatres of operation and grow our Canadian LNG drilling
leadership position. Be a recognized leader in the integrated
directional drilling transformation. Grow U.S. presence in Completion
and Production Services segments.
4. Increase returns for our investors.
For the fourth quarter of 2013, the average West Texas Intermediate price of oil was down slightly from the 2013 yearly averages while average AECO and Henry Hub natural gas prices were higher.
Three months ended Years ended
December 31, December 31,
2013 2012 2013 2012
----------------------------------------------------------------------------
Average oil and natural gas
prices
Oil
West Texas Intermediate
(per barrel) (US$) 97.50 88.10 98.02 94.13
Natural gas
Canada
AECO (per MMBtu) (Cdn$) 3.53 3.20 3.18 2.39
United States
Henry Hub (per MMBtu)
(US$) 3.85 3.40 3.73 2.75
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Summary for the three months ended December 31, 2013:
-- Operating earnings (see "Additional GAAP Measures" in this news release)
this quarter were $108 million, or 19% of revenue, compared to a loss of
$105 million in 2012. In the fourth quarter of 2012, we recorded a
charge of $192 million related to the decommissioning of 52 drilling
rigs, which reduced 2012 operating earnings. Operating earnings for 2013
were positively impacted by the increase in activity in our
international and U.S. operations offset by weaker demand for our
Canadian completion and production services, when compared to the fourth
quarter in 2012.
-- General and administrative expenses this quarter were $34 million, or $4
million higher than the fourth quarter of 2012 primarily because of the
year to date true up of incentive compensation costs tied to the price
of our common shares and operating results.
-- Net finance charges were $23 million, an increase of $1 million compared
with the fourth quarter of 2012 due to the increase in average
outstanding debt stated in Canadian dollars.
-- Average revenue per utilization day for contract drilling rigs in Canada
increased in the fourth quarter of 2013 to $22,932 from the prior year
fourth quarter of $21,997 and decreased in the United States to
US$23,841 from US$25,465 for the fourth quarter of 2012. The increase in
revenue rates for the fourth quarter in Canada was due to rig mix in
part from increased activity days from Tier 1 rigs compared to the prior
year quarter as new build and upgraded rigs entered the fleet. In the
United States, the average daily rate was down from the prior year
because of a reduction in turnkey activity. Excluding turnkey results,
the average U.S. contract drilling revenue per utilization day increased
US$318 from the fourth quarter of the prior year. In Canada, for the
fourth quarter of 2013, 44% of Precision's utilization days were
achieved from drilling rigs working under term contracts compared to 41%
in the 2012 comparative period. In the United States, for the fourth
quarter of 2013, 62% of Precision's utilization days were generated from
rigs working under term contracts compared to 64% in the 2012
comparative period. Turnkey revenue for the fourth quarter of 2013 was
US$17 million, compared with US$32 million in the 2012 comparative
period. Within our Completion and Production Services segment, average
hourly rates for service rigs were $878 in the fourth quarter of 2013
compared to $795 in the fourth quarter of 2012. The increase in the
average hourly rate was the result of an increase in coil tubing hours.
-- Average operating costs per utilization day for drilling rigs in Canada
increased in the fourth quarter of 2013 to $10,391 from the prior year
fourth quarter of $10,141 while in the United States costs decreased to
US$14,150 in 2013 from US$16,103 in 2012. The cost increase in Canada
was primarily due to the October crew wage increase. The cost decrease
per day in the United States was primarily due to lower turnkey activity
and cost efficiencies gained throughout the year. Excluding turnkey
results, the average U.S. contract drilling operating cost per
utilization day decreased US$882 from the fourth quarter of the prior
year. Within Precision's Completion and Production Services segment,
average hourly operating costs for service rigs increased to $703 in the
fourth quarter of 2013 as compared to $594 in the fourth quarter of 2012
primarily due to costs associated with coil tubing and fixed costs
spread over a lower activity base.
-- Precision realized revenue from international contract drilling of $47
million in the fourth quarter of 2013, a $24 million increase over the
prior year period. During the fourth quarter of 2013, one rig contract
in Mexico was terminated resulting in lump sum recognition of revenue of
US$3 million with no associated costs.
-- Precision realized revenue from directional services of $31 million in
the fourth quarter of 2013, a $4 million decrease from the prior year
period.
-- Funds provided by operations (see "Additional GAAP Measures" in this
news release) in the fourth quarter of 2013 were $156 million, an
increase of $13 million from the prior year comparative quarter of $143
million. The increase is the result of higher earnings for the quarter
compared to last year.
-- During December 2013, all of Precision's outstanding warrants were
exercised providing proceeds to Precision of $48 million.
-- Capital expenditures for the purchase of property, plant and equipment
were $123 million in the fourth quarter, a decrease of $64 million over
the same period in 2012. Capital spending for the fourth quarter of 2013
included $54 million for expansion capital, $30 million for upgrade
capital and $39 million for the maintenance of existing assets and
infrastructure spending.
Summary for the year ended December 31, 2013:
-- Revenue for 2013 was $2,030 million, a decrease of 1% from 2012.
-- Operating earnings were $306 million, an increase of $135 million or 79%
from 2012. Operating earnings were 15% of revenue in 2013 compared to 8%
in 2012. In 2012, we recorded a charge of $192 million related to the
decommissioning of 52 drilling rigs, which reduced 2012 operating
earnings.
-- General and administrative costs were $143 million, an increase of $16
million over 2012 primarily as a result of the increase in incentive
compensation costs tied to the performance of Precision's common shares
and costs associated with administration of increased international and
U.S. activities in 2013.
-- Net finance charges were $93 million, an increase of $6 million from
2012. The increase is primarily due to the increase in average
outstanding debt stated in Canadian dollars.
-- Funds provided by operations (see "Additional GAAP Measures" in this
news release) in 2013 were $462 million, a decrease of $137 million from
2012.
-- Capital expenditures for the purchase of property, plant and equipment
were $536 million in 2013 a decrease of $332 million over 2012. Capital
spending for 2013 included $282 million for expansion capital, $141
million for upgrade capital and $113 million for the maintenance of
existing assets and infrastructure.
OUTLOOK
Contracts
Our portfolio of term customer contracts provides a base level of activity and revenue and, as of February 12, 2014, we have term contracts in place for an average of 57 rigs in Canada, 53 in the United States and eight internationally for the first quarter of 2014 and an average of 51 rig contracts in Canada, 41 in the United States and seven internationally for the full year. In Canada, term contracted rigs normally generate 250 utilization days per year because of the seasonal nature of well site access. In most regions in the United States and internationally, term contracts normally generate 365 utilization days per year.
Drilling Activity
In the United States, our average active rig count in the quarter was 90 rigs, up three rigs over the fourth quarter in 2012 and up nine rigs over the third quarter of 2013. We currently have 95 rigs active in the United States.
In Canada, our average active rig count in the quarter was 89 rigs, the same as the fourth quarter in 2012 and up six rigs over the third quarter of 2013. We currently have 144 rigs active in Canada and expect the strength of drilling activity in the first quarter to be driven in large part by weather. We expect to benefit from the fleet enhancements made over the past few years when compared to the prior year period.
Internationally, our average active rig count in the quarter was 11 rigs, up three rigs over the fourth quarter in 2012 and in line with the third quarter of 2013. We currently have 11 rigs active internationally and expect our active rig count to grow over the next two quarters as two new build rigs for the Kuwait market are delivered late in the second quarter, and we see potential for additional rigs going to work in Mexico.
Industry Conditions
To date in 2014, drilling activity has been similar to this time last year for both Canada and the United States. According to industry sources, as of February 7, 2014, the U.S. active land drilling rig count was up about 1% from the same point last year and the Canadian active land drilling rig count had decreased about 2%. Despite the active industry rig count softness, demand for Tier 1 assets continues to be strong, benefiting drilling contractors, like Precision, with a high percentage of Tier 1 assets.
Canada has been experiencing an increase in natural gas and gas liquids drilling activity related to deep basin drilling in northwestern Alberta and northeastern British Columbia while the trend towards oil-directed drilling in the United States has continued in 2014. To date in 2014, approximately 64% of the Canadian industry's active rigs and 80% of the U.S. industry's active rigs were drilling for oil targets, compared to 73% for Canada and 76% for the U.S. at the same time last year.
Capital Spending
Capital spending in 2014 is expected to be $515 million:
-- The 2014 capital expenditure plan includes $268 million for expansion
capital, $195 million for sustaining and infrastructure expenditures,
and $52 million to upgrade existing rigs. We expect that the $515
million will be split $478 million in the Contract Drilling segment and
$37 million in the Completion and Production Services segment.
-- Precision's expansion capital plan includes 11 new build drilling rigs
including six for Canada, two for the United States, two for Kuwait and
one Super Triple ST-1500 rig which will only be completed once a firm
customer contract is secured. The six rigs for Canada include five ST-
1500 rigs for northern gas and gas liquids drilling and one Precision
Super Single for heavy oil development drilling. The U.S. new builds
consist of two ST-1500 rigs while in Kuwait two ST-3000 rigs are
expected to be deployed late in the second quarter. Additional expansion
capital is allocated to equipment for Completion and Production Service,
and long-lead items.
-- The 2014 capital plan includes 10 to 14 rig upgrades, four of which
represent the completion of the 2013 rig upgrade program.
-- Precision's sustaining and infrastructure capital plan is based upon
currently anticipated activity levels for 2014 and includes a technical
and operational support centre in Nisku, Alberta along with regional
support facilities and corporate systems. The Nisku centre consolidates
Precision's existing Canadian operations and technical support centres
and will contain a new employee training centre complete with a fully
functional training rig equipped with the latest drilling technology.
The Nisku facility is expected to support Canadian operations for
several decades, provide increased capacity and efficiency, and ensure
that we continue to deliver services with highly skilled and well
trained field personnel. The portion of the 2014 budget allocated to
this facility is approximately $30 million.
SEGMENTED FINANCIAL RESULTS
Precision's operations are reported in two segments: the Contract Drilling Services segment, which includes the drilling rig, directional drilling, trucking, oilfield supply and manufacturing operations; and the Completion and Production Service segment which includes the service rig, snubbing, coil tubing, rental, camp and catering and wastewater treatment operations.
(Stated in thousands Three months
of Canadian ended Year ended
dollars) December 31, December 31,
% %
2013 2012 Change 2013 2012 Change
----------------------------------------------------------------------------
Revenue:
Contract Drilling
Services 484,349 452,104 7.1 1,719,910 1,725,240 (0.3)
Completion and
Production
Services 85,385 85,225 0.2 323,353 326,079 (0.8)
Inter-segment
eliminations (2,825) (3,381) (16.4) (13,286) (10,578) 25.6
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566,909 533,948 6.2 2,029,977 2,040,741 (0.5)
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Adjusted EBITDA:(1)
Contract Drilling
Services 200,271 172,169 16.3 653,664 649,281 0.7
Completion and
Production
Services 16,261 22,222 (26.8) 61,032 93,554 (34.8)
Corporate and Other (18,788) (17,365) 8.2 (75,863) (72,043) 5.3
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197,744 177,026 11.7 638,833 670,792 (4.8)
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(1) See "ADDITIONAL GAAP MEASURES".
SEGMENT REVIEW OF CONTRACT DRILLING SERVICES
(Stated in thousands
of Canadian Three months
dollars, except ended Year ended
where noted) December 31, December 31,
% %
2013 2012 Change 2013 2012 Change
----------------------------------------------------------------------------
Revenue 484,349 452,104 7.1 1,719,910 1,725,240 (0.3)
Expenses:
Operating 273,107 270,804 0.9 1,019,156 1,036,553 (1.7)
General and
administrative 10,971 9,131 20.2 47,090 39,406 19.5
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Adjusted EBITDA(1) 200,271 172,169 16.3 653,664 649,281 0.7
Depreciation 79,687 78,327 1.7 292,217 271,993 7.4
Loss on asset
decommissioning - 192,469 (100.0) - 192,469 (100.0)
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Operating earnings
(loss)(1) 120,584 (98,627) n/m 361,447 184,819 95.6
----------------------------------------------------------------------------
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Operating earnings
(loss) as a
percentage of
revenue 24.9% (21.8%) 21.0% 10.7%
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Drilling rig revenue
per utilization day
in Canada (Cdn$) 22,932 21,997 4.3 22,108 21,030 5.1
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Drilling rig revenue
per utilization day
in the United
States(2) (US$) 23,841 25,465 (6.4) 23,575 23,696 (0.5)
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(1) See "ADDITIONAL GAAP MEASURES".
(2) Includes revenue from idle but contracted rig days.
n/m - calculation not meaningful
Three months ended December 31,
Canadian onshore drilling
statistics:(1) 2013 2012
----------------------------------------------------------------------------
Precision Industry(2) Precision Industry(2)
----------------------------------------------------------------------------
Number of drilling rigs (end
of period) 187 819 186 822
Drilling rig operating days
(spud to release) 7,202 32,517 7,269 30,849
Drilling rig operating day
utilization 42% 43% 39% 40%
Number of wells drilled 873 2,975 862 2,813
Average days per well 8.2 10.9 8.4 11.0
Number of metres drilled
(000s) 1,489 6,301 1,435 5,856
Average metres per well 1,706 2,118 1,665 2,082
Average metres per day 207 194 197 190
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Year ended December 31,
Canadian onshore drilling
statistics:(1) 2013 2012
----------------------------------------------------------------------------
Precision Industry(2) Precision Industry(2)
----------------------------------------------------------------------------
Number of drilling rigs (end
of period) 187 819 186 822
Drilling rig operating days
(spud to release) 26,983 120,043 28,848 124,319
Drilling rig operating day
utilization 39% 40% 40% 42%
Number of wells drilled 3,211 10,903 3,085 10,753
Average days per well 8.4 11.0 9.4 11.6
Number of metres drilled
(000s) 5,576 22,733 5,233 20,869
Average metres per well 1,736 2,085 1,696 1,941
Average metres per day 207 189 181 168
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(1) Canadian operations only.
(2) Canadian Association of Oilwell Drilling Contractors ("CAODC") and
Precision - excludes non-CAODC rigs and non-reporting CAODC members.
United States onshore
drilling statistics:(1) 2013 2012
----------------------------------------------------------------------------
Precision Industry(2) Precision Industry(2)
----------------------------------------------------------------------------
Average number of active
land rigs for quarters
ended:
March 31 81 1,706 104 1,947
June 30 80 1,710 97 1,924
September 30 81 1,709 90 1,855
December 31 90 1,697 87 1,759
----------------------------------------------------------------------------
Annual average 83 1,705 95 1,871
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(1) United States lower 48 land operations only.
(2) Baker Hughes rig counts.
Revenue from Contract Drilling Services was $484 million this quarter, or 7% higher than the fourth quarter of 2012, while adjusted EBITDA increased by 16% to $200 million. The increases were mainly due to higher drilling rig utilization in our international business and in the United States as well as higher average dayrates in the Canadian market partially offset by lower turnkey activity in the United States.
Operating results for our international business improved as we averaged 11 rigs working compared to eight in the prior year comparative quarter. Drilling utilization days in our international operations for the quarter were 1,052 days, 43% higher than the prior year comparative period.
Drilling rig utilization days in Canada (drilling days plus move days) during the fourth quarter of 2013 were 8,201, a decrease of 1% compared to 2012 while drilling rig utilization days in the United States were 8,258, or 3% higher than the same quarter of 2012. The increase in U.S. activity was primarily due to strong demand for Tier 1 assets and resulted in market share gains by Precision during the second half of the year. The majority of our North America activity came from oil and liquids-rich natural gas related plays.
Drilling rig revenue per utilization day was up 4% in Canada and down 6% in the U.S. compared to the same quarter in 2012. The increase in average dayrates for Canada was the result of improved rig mix and continued demand for Tier 1 assets. In the U.S., the decrease in the average dayrate was driven by lower turnkey revenue.
In Canada, 44% of utilization days in the fourth quarter were generated from rigs under term contract, compared to 41% in the fourth quarter of 2012. In the U.S., 62% of utilization days were generated from rigs under term contract as compared to 64% in the fourth quarter of 2012. At the end of the quarter, we had 57 drilling rigs under contract in Canada, 58 in the U.S. and 10 internationally.
Operating costs were 56% of revenue for the quarter, which was four percentage points lower than the prior year period. On a per utilization day basis, operating costs for the drilling rig division in Canada were above the prior year primarily because of an increase in crew wage expense. In the U.S., operating costs for the quarter on a per day basis were down from the fourth quarter in 2012 as a result of proportionately lower turnkey activity and cost savings from operational efficiencies.
Depreciation expense in the quarter was 2% higher than in the fourth quarter of 2012 due to an increase in overall drilling activity and a greater proportion of operating days from our Tier 1 drilling rigs in 2013 relative to 2012. With the exception of certain PSST drilling rigs and directional drilling equipment, contract drilling operations use the unit of production method of calculating depreciation.
SEGMENT REVIEW OF COMPLETION AND PRODUCTION SERVICES
(Stated in thousands
of Canadian Three months
dollars, except ended Year ended
where noted) December 31, December 31,
% %
2013 2012 Change 2013 2012 Change
----------------------------------------------------------------------------
Revenue 85,385 85,225 0.2 323,353 326,079 (0.8)
Expenses:
Operating 65,199 59,383 9.8 242,768 217,326 11.7
General and
administrative 3,925 3,620 8.4 19,553 15,199 28.6
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Adjusted EBITDA(1) 16,261 22,222 (26.8) 61,032 93,554 (34.8)
Depreciation 8,324 8,983 (7.3) 32,630 30,758 6.1
----------------------------------------------------------------------------
Operating
earnings(1) 7,937 13,239 (40.0) 28,402 62,796 (54.8)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Operating earnings
as a percentage of
revenue 9.3% 15.5% 8.8% 19.3%
----------------------------------------------------------------------------
Well servicing
statistics:
Number of service
rigs (end of
period) 222 214 3.7 222 214 3.7
Service rig
operating hours 71,981 77,234 (6.8) 283,576 294,681 (3.8)
Service rig
operating hour
utilization 35% 38% 36% 38%
Service rig revenue
per operating hour
(Cdn$) 878 795 10.4 854 744 14.8
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(1) See "ADDITIONAL GAAP MEASURES".
Revenue from Completion and Production Services was in line with the fourth quarter of 2012, as weaker demand in the Canadian market offset the expansion of services in the United States. Activity in Canadian well servicing was down 16% but was offset by a 158% increase is U.S. well servicing activity and higher average hourly rates in both Canada and the United States. Adjusted EBITDA was $6 million lower than the fourth quarter of 2012 due to weaker demand in Canada and higher costs in the United States.
Well servicing activity in the fourth quarter was 7% lower than the fourth quarter of 2012, as lower customer demand in Canada partially offset our growing U.S. presence. Approximately 83% of the fourth quarter service rig activity was oil related. Our rental division activity in the fourth quarter was lower than the fourth quarter of 2012 mainly due to the excess amount of surface storage capacity in Western Canada.
Average service rig revenue per operating hour in the fourth quarter was $878, or $83 higher than the fourth quarter of 2012. The increase was primarily the result of increased coil tubing operations in the current quarter, which operate at higher rates.
Operating costs as a percentage of revenue increased to 76% in the fourth quarter of 2013, from 70% in the fourth quarter of 2012. Operating costs per service rig operating hour were higher than in the fourth quarter of 2012 mainly because of the increase in costs associated with the new coil tubing operations and fixed costs spread over a lower activity base.
Depreciation in the fourth quarter of 2013 was 7% lower than the fourth quarter of 2012 because of lower equipment utilization and losses on disposal realized in the prior year comparative quarter. We use the straight-line method of calculating depreciation for our completion and production business lines, except for the well servicing division, where we use the unit of production method.
SEGMENT REVIEW OF CORPORATE AND OTHER
Our Corporate and Other segment provides support functions to our operating segments. The Corporate and Other segment had an adjusted EBITDA loss of $19 million for the fourth quarter of 2013, $1 million higher than the prior year comparative period due to higher incentive plan compensation.
OTHER ITEMS
Net financial charges for the quarter were $23 million, an increase of $1 million from the fourth quarter of 2012.
We had a foreign exchange gain of $4 million during the fourth quarter of 2013 due to the weakening of the Canadian dollar versus the U.S. dollar, which affected the net U.S. dollar denominated monetary position in the Canadian dollar-based companies.
Income tax expense for the quarter was $20 million compared with a recovery of $61 million in the same quarter in 2012. The increase is primarily the result of an increase in operating results.
In June 2013, a wholly owned subsidiary of Precision lost a tax appeal in the Ontario Superior Court of Justice related to a reassessment of Ontario income tax for the subsidiary's 2001 through 2004 taxation years. Precision has appealed the decision to the Ontario Court of Appeal and we expect this appeal to be heard in the latter half of 2014. Despite the decision in the Superior Court, management believes it is more likely than not that Precision will prevail on appeal. Should Precision lose on appeal, approximately $55 million of the long-term income tax recoverable related to this issue would be expensed.
LIQUIDITY AND CAPITAL RESOURCES
The oilfield services business is inherently cyclical in nature. To manage this, we focus on maintaining a strong balance sheet so we have the financial flexibility we need to continue to manage our growth and cash flow, no matter where we are in the business cycle.
We apply a disciplined approach to managing and tracking results of our operations to keep costs down. We maintain a variable cost structure so we can be responsive to changes in demand.
Our maintenance capital expenditures are tightly governed by and highly responsive to activity levels with additional cost savings leverage provided through our internal manufacturing and supply divisions. Term contracts on expansion capital for new build rig programs provide more certainty of future revenues and return on our capital investments.
Liquidity
As at December 31, 2013, our liquidity was supported by a cash balance of $81 million, an undrawn balance on our senior secured credit facility of approximately US$793 million availability on our operating facilities totaling approximately $40 million and approximately US$25 million available on a secured facility for letters of credit
At December 31, 2013, including letters of credit, we had approximately $1,394 million outstanding under our secured and unsecured credit facilities and $23 million in unamortized debt issue costs.
Amount Availability Used for Maturity
----------------------------------------------------------------------------
Senior facility
(secured)
----------------------------------------------------------------------------
US$850 million Drawn US$28 General corporate November 17, 2018
(extendible, million and US$28 purposes
revolving term million in
credit facility outstanding
with US$250 million letters of credit
accordion feature)
----------------------------------------------------------------------------
Operating facilities (secured)
----------------------------------------------------------------------------
$40 million Undrawn, except Letters of credit
$17 million in and general
outstanding corporate purposes
letters of credit
----------------------------------------------------------------------------
US$15 million Undrawn Short term working
capital
requirements
----------------------------------------------------------------------------
Demand letter of credit facility (secured)
----------------------------------------------------------------------------
US$25 million Undrawn, except Letters of credit
$0.2 million in
outstanding
letters of credit
----------------------------------------------------------------------------
Senior notes (unsecured)
----------------------------------------------------------------------------
$200 million Fully drawn Debt repayment March 15, 2019
----------------------------------------------------------------------------
US$650 million Fully drawn Debt repayment and November 15, 2020
general corporate
purposes
----------------------------------------------------------------------------
US$400 million Fully drawn Capital December 15, 2021
expenditures and
general corporate
purposes
----------------------------------------------------------------------------
Our secured facility includes financial ratio covenants that are tested quarterly; we are compliant with these covenants and expect to remain compliant.
The current blended cash interest cost of our debt is about 6.5%.
Hedge of investments in U.S. operations
We have designated our U.S. dollar denominated long-term debt as a hedge of our investment in our operations in the United States. To be accounted for as a hedge, the foreign currency denominated long-term debt must be designated and documented as such and must be effective at inception and on an ongoing basis. We recognize the effective amount of this hedge (net of tax) in other comprehensive income. We recognize ineffective amounts (if any) in earnings.
Average shares outstanding
In December 2013, we issued 15 million shares upon the exercise of warrants for cash of $48 million. The following table reconciles the weighted average shares outstanding used in computing basic and diluted earnings per share:
----------------------------------------------------------------------------
Three months ended Year ended
December 31, December 31,
2013 2012 2013 2012
----------------------------------------------------------------------------
Weighted average shares
outstanding - basic 280,388 276,372 277,583 276,276
Effect of warrants 7,710 8,661 9,327 9,418
Effect of share options and
other equity compensation
plans 913 780 971 933
----------------------------------------------------------------------------
Weighted average shares
outstanding - diluted 289,011 285,813 287,881 286,627
----------------------------------------------------------------------------
----------------------------------------------------------------------------
QUARTERLY FINANCIAL SUMMARY
(Stated in thousands of Canadian dollars, except per share amounts)
2013
----------------------------------------------------------------------------
Quarters ended March 31 June 30 September 30 December 31
----------------------------------------------------------------------------
Revenue 595,720 378,898 488,450 566,909
Adjusted EBITDA(1) 215,181 88,248 137,660 197,744
Net earnings: 93,313 473 29,443 67,921
Per basic share 0.34 0.00 0.11 0.24
Per diluted share 0.33 0.00 0.10 0.24
Funds provided by
operations(1) 144,682 33,791 127,684 155,816
Cash provided by
operations 62,948 182,345 88,341 94,452
Dividends per share 0.05 0.05 0.05 0.06
----------------------------------------------------------------------------
2012
----------------------------------------------------------------------------
Quarters ended March 31 June 30 September 30 December 31
----------------------------------------------------------------------------
Revenue 640,066 381,966 484,761 533,948
Adjusted EBITDA(1) 245,574 97,192 151,000 177,026
Net earnings (loss): 111,081 18,261 39,357 (116,339)
Per basic share 0.40 0.07 0.14 (0.42)
Per diluted share 0.39 0.06 0.14 (0.42)
Funds provided by
operations(1) 247,739 62,373 146,124 142,576
Cash provided by
operations 162,440 275,346 61,183 136,317
Dividends per share - - - 0.05
----------------------------------------------------------------------------
(1) See "ADDITIONAL GAAP MEASURES".
ADDITIONAL GAAP MEASURES
We reference Generally Accepted Accounting Principles (GAAP) measures that are not defined terms under International Financial Reporting Standards to assess performance because we believe they provide useful supplemental information to investors.
Adjusted EBITDA
We believe that adjusted EBITDA (earnings before income taxes, financing charges, foreign exchange, impairment of goodwill, loss on asset decommissioning and depreciation and amortization) as reported in the Consolidated Statement of Earnings (Loss) is a useful measure, because it gives an indication of the results from our principal business activities prior to consideration of how our activities are financed and the impact of foreign exchange, taxation and non-cash depreciation and amortization charges.
Operating Earnings (Loss)
We believe that operating earnings (loss), as reported in the Consolidated Statements of Earnings (Loss), is a useful measure because it provides an indication of the results of our principal business activities before consideration of how those activities are financed and the impact of foreign exchange and taxation.
Funds Provided by Operations
We believe that funds provided by operations, as reported in the Consolidated Statements of Cash Flow is a useful measure because it provides an indication of the funds our principal business activities generate prior to consideration of working capital, which is primarily made up of highly liquid balances.
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION AND STATEMENTS
Certain statements contained in this report, including statements that contain words such as "could", "should", "can", "anticipate", "estimate", "intend", "plan", "expect", "believe", "will", "may", "continue", "project", "potential" and similar expressions and statements relating to matters that are not historical facts constitute "forward-looking information" within the meaning of applicable Canadian securities legislation and "forward-looking statements" within the meaning of the "safe harbor" provisions of the United States Private Securities Litigation Reform Act of 1995 (collectively, "forward-looking information and statements").
In particular, forward looking information and statements include, but are not limited to, the following: the payment of our declared first quarter dividend; the expected deployment of two additional rigs to Kuwait and our increased market penetration in Mexico; our plans to continue executing our High Performance, High Value strategy; our plans to leverage our scale in operations to promote consistent and reliable service and to reduce our operating costs; our ability to deliver new build and upgraded rigs to our customers on a timely basis; our plans to expand our international activity in existing theatres of operation, to grow our Canadian LNG drilling leadership position and to grow our Completion and Production Services segment in the U.S.; delivering increased returns for our investors; the expected weather impact on our Canadian drilling operations; our capital spending plans and projections including plans to expand our fleet with 11 new build drilling rigs and the upgrading of 10 to 14 existing rigs; the expected completion of our Nisku technical support centre and its future impact on our operational capabilities; the appeal process and potential liability arising from the income tax reassessment in Ontario of one of our wholly-owned subsidiaries; and our ability to remain compliant with our financial ratio covenants under our secured facility.
These forward-looking information and statements are based on certain assumptions and analysis made by Precision in light of our experience and our perception of historical trends, current conditions and expected future developments as well as other factors we believe are appropriate in the circumstances. However, whether actual results, performance or achievements will conform to our expectations and predictions is subject to a number of known and unknown risks and uncertainties which could cause actual results to differ materially from our expectations. Such risks and uncertainties include, but are not limited to: fluctuations in the price and demand for oil and natural gas; fluctuations in the level of oil and natural gas exploration and development activities; fluctuations in the demand for contract drilling, well servicing and ancillary oilfield services; capital market liquidity available to fund customer drilling programs; availability of cash flow, debt and/or equity sources to fund Precision's capital and operating requirements, as needed; sustainability of our dividend; the effects of seasonal and weather conditions on operations and facilities; the existence of competitive operating risks inherent in our businesses; general economic, market or business conditions; changes in laws or regulations; the availability of qualified personnel, management or other key inputs; currency exchange fluctuations; and other unforeseen conditions which could impact the use of services supplied by Precision and Precision's ability to respond to such conditions.
Consequently, all of the forward-looking information and statements made in this report are qualified by these cautionary statements and there can be no assurance that the actual results or developments anticipated by Precision will be realized or, even if substantially realized, that they will have the expected consequences to, or effects on, Precision or its business or operations. Readers are therefore cautioned not to place undue reliance on such forward-looking information and statements. Except as may be required by law, Precision assumes no obligation to update publicly any such forward-looking information and statements, whether as a result of new information, future events or otherwise.
table
CONSOLIDATED STATEMENTS OF FINANCIAL POSITION
(UNAUDITED)
December 31, December 31,
(Stated in thousands of Canadian dollars) 2013 2012
----------------------------------------------------------------------------
ASSETS
Current assets:
Cash $80,606 $ 152,768
Accounts receivable 549,697 509,547
Inventory 12,378 13,787
----------------------------------------------------------------------------
Total current assets 642,681 676,102
Non-current assets:
Income tax recoverable 58,435 64,579
Property, plant and equipment 3,561,734 3,242,929
Intangibles 3,917 6,101
Goodwill 312,356 310,552
----------------------------------------------------------------------------
Total non-current assets 3,936,442 3,624,161
----------------------------------------------------------------------------
Total assets $4,579,123 $4,300,263
----------------------------------------------------------------------------
----------------------------------------------------------------------------
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable and accrued liabilities $332,838 $333,893
Income tax payable 4,060 64,188
----------------------------------------------------------------------------
Total current liabilities 336,898 398,081
Non-current liabilities:
Share based compensation 14,431 8,676
Provisions and other 17,836 17,818
Long-term debt 1,323,268 1,218,796
Deferred tax liabilities 487,347 485,592
----------------------------------------------------------------------------
Total non-current liabilities 1,842,882 1,730,882
Shareholders' equity:
Shareholders' capital 2,305,227 2,251,982
Contributed surplus 29,175 24,474
Retained earnings (deficit) 88,416 (44,621)
Accumulated other comprehensive loss (23,475) (60,535)
----------------------------------------------------------------------------
Total shareholders' equity 2,399,343 2,171,300
----------------------------------------------------------------------------
Total liabilities and shareholders' equity $4,579,123 $4,300,263
----------------------------------------------------------------------------
----------------------------------------------------------------------------
CONSOLIDATED STATEMENTS OF EARNINGS (LOSS) (UNAUDITED)
Three months ended Year ended
December 31, December 31,
(Stated in thousands of
Canadian dollars,
except per share
amounts) 2013 2012 2013 2012
----------------------------------------------------------------------------
Revenue $ 566,909 $ 533,948 $ 2,029,977 $ 2,040,741
Expenses:
Operating 335,480 326,806 1,248,637 1,243,301
General and
administrative 33,685 30,116 142,507 126,648
----------------------------------------------------------------------------
Earnings before income
taxes, finance charges,
foreign exchange,
impairment of goodwill,
loss on asset
decommissioning and
depreciation and
amortization 197,744 177,026 638,833 670,792
Depreciation and
amortization 90,142 89,278 333,159 307,525
Loss on asset
decommissioning - 192,469 - 192,469
----------------------------------------------------------------------------
Operating earnings
(loss) 107,602 (104,721) 305,674 170,798
Impairment of goodwill - 52,539 - 52,539
Foreign exchange (3,687) (1,857) (9,112) 3,753
Finance charges 23,328 22,107 93,248 86,829
----------------------------------------------------------------------------
Earnings (loss) before
income taxes 87,961 (177,510) 221,538 27,677
Income taxes:
Current 14,681 23,416 45,017 70,576
Deferred 5,359 (84,587) (14,629) (95,259)
----------------------------------------------------------------------------
20,040 (61,171) 30,388 (24,683)
----------------------------------------------------------------------------
Net earnings (loss) $ 67,921 $ (116,339) $ 191,150 $ 52,360
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Net earnings (loss) per
share:
Basic $ 0.24 $ (0.42) $ 0.69 $ 0.19
Diluted $ 0.24 $ (0.42) $ 0.66 $ 0.18
----------------------------------------------------------------------------
----------------------------------------------------------------------------
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (UNAUDITED)
Three months ended Year ended
December 31, December 31,
(Stated in thousands of
Canadian dollars) 2013 2012 2013 2012
----------------------------------------------------------------------------
Net earnings (loss) $ 67,921 $ (116,339) $ 191,150 $ 52,360
Unrealized gain (loss)
on translation of
assets and liabilities
of operations
denominated in foreign
currency 57,780 16,598 109,195 (32,878)
Foreign exchange gain
(loss) on net
investment hedge with
U.S. denominated debt,
net of tax (36,855) (10,228) (72,135) 23,205
----------------------------------------------------------------------------
Comprehensive income
(loss) $ 88,846 $ (109,969) $ 228,210 $ 42,687
----------------------------------------------------------------------------
----------------------------------------------------------------------------
CONSOLIDATED STATEMENTS OF CASH FLOW (UNAUDITED)
Three months ended Year ended
December 31, December 31,
(Stated in thousands of
Canadian dollars) 2013 2012 2013 2012
----------------------------------------------------------------------------
Cash provided by (used
in):
Operations:
Net earnings (loss) $ 67,921 $ (116,339) $ 191,150 $ 52,360
Adjustments for:
Long-term compensation
plans 4,231 4,293 20,708 19,350
Depreciation and
amortization 90,142 89,278 333,159 307,525
Loss on asset
decommissioning - 192,469 - 192,469
Impairment of goodwill - 52,539 - 52,539
Foreign exchange (4,703) (1,689) (9,216) 4,403
Finance charges 23,328 22,107 93,248 86,829
Income taxes 20,040 (61,171) 30,388 (24,683)
Other (3,345) (1,019) (3,754) 1,018
Income taxes paid (6,651) (3,088) (109,326) (10,403)
Income taxes recovered 1,674 108 3,761 721
Interest paid (37,276) (35,287) (89,156) (85,251)
Interest received 455 375 1,011 1,935
----------------------------------------------------------------------------
Funds provided by
operations 155,816 142,576 461,973 598,812
Changes in non-cash
working capital balances (61,364) (6,259) (33,887) 36,474
----------------------------------------------------------------------------
94,452 136,317 428,086 635,286
Investments:
Business acquisitions,
net of cash acquired - - - (25)
Purchase of property,
plant and equipment (123,042) (186,650) (535,804) (868,057)
Proceeds on sale of
property, plant and
equipment 3,351 17,603 13,372 31,423
Changes in income tax
recoverable 6,144 - 6,144 -
Changes in non-cash
working capital balances (26,690) (31,052) (10,247) (93,462)
----------------------------------------------------------------------------
(140,237) (200,099) (526,535) (930,121)
Financing:
Dividends paid (16,618) (13,821) (58,113) (13,821)
Debt issue costs - - (883) (2,855)
Debt facility amendment
costs - - - (149)
Increase in long-term
debt 14,781 - 29,781 -
Issuance of common shares
on the exercise of
options 278 436 2,432 1,926
Issuance of common shares
on the exercise of
warrants 48,300 - 48,300 -
----------------------------------------------------------------------------
46,741 (13,385) 21,517 (14,899)
----------------------------------------------------------------------------
Effect of exchange rate
changes on cash and cash
equivalents (2,165) 3,094 4,770 (4,974)
----------------------------------------------------------------------------
Decrease in cash and cash
equivalents (1,209) (74,073) (72,162) (314,708)
Cash and cash equivalents,
beginning of period 81,815 226,841 152,768 467,476
----------------------------------------------------------------------------
Cash and cash equivalents,
end of period $ 80,606 $ 152,768 $ 80,606 $ 152,768
----------------------------------------------------------------------------
----------------------------------------------------------------------------
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (UNAUDITED)
(Stated in thousands of Canadian dollars)
----------------------------------------------------------------------------
Accumulated
other
Shareholders' Contributed comprehensive
capital surplus loss
----------------------------------------------------------------------------
Balance at January 1, 2013 $ 2,251,982 $ 24,474 $ (60,535)
Net earnings for the period - - -
Other comprehensive income for
the period - - 37,060
Dividends - - -
Share options exercised 3,707 (1,275) -
Shares issued on redemption of
non-management directors DSUs 1,238 (1,031) -
Warrants exercised 48,300 - -
Share based compensation
expense - 7,007 -
----------------------------------------------------------------------------
Balance at December 31, 2013 $ 2,305,227 $ 29,175 $ (23,475)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Retained
earnings Total
(deficit) equity
----------------------------------------------------------------------------
Balance at January 1, 2013 $ (44,621) $ 2,171,300
Net earnings for the period 191,150 191,150
Other comprehensive income for
the period - 37,060
Dividends (58,113) (58,113)
Share options exercised - 2,432
Shares issued on redemption of
non-management directors DSUs - 207
Warrants exercised - 48,300
Share based compensation
expense - 7,007
----------------------------------------------------------------------------
Balance at December 31, 2013 $ 88,416 $ 2,399,343
----------------------------------------------------------------------------
----------------------------------------------------------------------------
(Stated in thousands of Canadian dollars)
----------------------------------------------------------------------------
Accumulated
other
Shareholders' Contributed comprehensive
capital surplus loss
----------------------------------------------------------------------------
Balance at January 1, 2012 $ 2,248,217 $ 18,396 $ (50,862)
Net earnings for the period - - -
Other comprehensive loss for
the period - - (9,673)
Dividends - - -
Share options exercised 3,050 (1,124) -
Shares issued on redemption of
non-management directors DSUs 706 (706) -
Shares issued on waiver of
right to dissent by dissenting
unitholder 9 (3) -
Share based compensation
expense - 7,911 -
----------------------------------------------------------------------------
Balance at December 31, 2012 $ 2,251,982 $ 24,474 $ (60,535)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Total
Deficit equity
----------------------------------------------------------------------------
Balance at January 1, 2012 $ (83,160) $ 2,132,591
Net earnings for the period 52,360 52,360
Other comprehensive loss for
the period - (9,673)
Dividends (13,821) (13,821)
Share options exercised - 1,926
Shares issued on redemption of
non-management directors DSUs - -
Shares issued on waiver of
right to dissent by dissenting
unitholder - 6
Share based compensation
expense - 7,911
----------------------------------------------------------------------------
Balance at December 31, 2012 $ (44,621) $ 2,171,300
----------------------------------------------------------------------------
----------------------------------------------------------------------------
FOURTH QUARTER 2014 EARNINGS CONFERENCE CALL AND WEBCAST
Precision Drilling Corporation has scheduled a conference call and webcast to begin promptly at 12:00 noon MT (2:00 p.m. ET) on Thursday, February 13, 2014.
The conference call dial in numbers are 1-866-226-1793 or 416-340-2216.
A live webcast of the conference call will be accessible on Precision's website at www.precisiondrilling.com by selecting "Investor Centre", then "Webcasts". Shortly after the live webcast, an archived version will be available for approximately 30 days.
An archived recording of the conference call will be available approximately one hour after the completion of the call until March 13, 2014 by dialing 1-800-408-3053 or 905-694-9451, passcode 5078039.
About Precision
Precision is a leading provider of safe and High Performance, High Value services to the oil and gas industry. Precision provides customers with access to an extensive fleet of contract drilling rigs, directional drilling services, well service and snubbing rigs, coil tubing services, camps, rental equipment, and wastewater treatment units backed by a comprehensive mix of technical support services and skilled, experienced personnel.
Precision is headquartered in Calgary, Alberta, Canada. Precision is listed on the Toronto Stock Exchange under the trading symbol "PD" and on the New York Stock Exchange under the trading symbol "PDS".
FOR FURTHER INFORMATION PLEASE CONTACT:
Precision Drilling Corporation
Carey Ford
Vice President, Finance and Investor Relations
403.716.4575
403.716.4755 (FAX)
Precision Drilling Corporation
Suite 800, 525 - 8th Avenue S.W.
Calgary, Alberta, Canada T2P 1G1
www.precisiondrilling.com
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